US5151203A - Composition and method for cementing a well - Google Patents
Composition and method for cementing a well Download PDFInfo
- Publication number
- US5151203A US5151203A US07/718,679 US71867991A US5151203A US 5151203 A US5151203 A US 5151203A US 71867991 A US71867991 A US 71867991A US 5151203 A US5151203 A US 5151203A
- Authority
- US
- United States
- Prior art keywords
- slurry
- percent
- aluminate
- water
- weight
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Lifetime
Links
Classifications
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
- C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
- C04B28/04—Portland cements
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
Definitions
- This invention relates to the construction of wells.
- the invention further relates to primary cementing operations involved in the construction of wells penetrating subterranean formations.
- This invention still further relates to hydraulic cementing compositions and methods of using them to perform primary cementing operations.
- the mass of hardened cement is referred to as the sheath.
- the cementing procedure thus described leading to and terminating with the construction of the sheath is referred to as primary cementing.
- the objectives of the sheath are to provide physical support and positioning of the casing in the borehole; to bond the casing to the walls of the borehole; to prevent the movement of fluid (liquid or gas) between formations penetrated by the borehole; and to prevent fluid from completely escaping the well at the surface of the earth.
- the compressive strength of set hydraulic cement in the sheath preferably shall be at least about 500 pounds per square inch before further operations may be conducted, wherein the time required to develop the strength, measured from the completion of the placement of the slurry in the annulus, preferably shall not exceed about 24 hours. This time delay is referred to in the art as waiting-on-cement or simply as WOC.
- the slurry movement rapidly changes from a moving, or dynamic, condition when being placed, to a resting, or static, condition after being placed.
- the slurry when in the static condition and not yet set, must immediately resist movement of formation fluid through the slurry.
- Such movement which is generally gas moving under the influence of formation pressure, is referred to as annular gas migration or simply as gas migration.
- the slurry itself when in the static condition, must resist any movement by it into subterranean zones with which the slurry is in communication.
- Such movement is generally due to the influence of hydrostatic pressure of the slurry on the zone and is referred to as fall back because the height of slurry in the annulus is reduced by the quantity of slurry penetrating the zone.
- Gas migration in the slurry leads directly to gas migration in the sheath, and can cause poor bonding of cement, casing and borehole. Fall back can result in a reduction of the quantity of sheath required to position and support the casing in the borehole. Accordingly, gas migration through the slurry and fall back of the slurry can frustrate the stated objectives of the sheath.
- This invention provides a composition for and a method of cementing a casing in a borehole whereby gas migration and fall back ar substantially reduced if not eliminated.
- static gel strength generally refers to the capacity of a fluid under static conditions to resist being moved by a shear force or simply as shear resistance.
- the fluid under consideration is a slurry of a hydraulic cement in water
- the expression more specifically refers to the resistance to movement, or internal rigidity, developed by the slurry when the slurry is not in motion.
- a slurry having a sufficiently high static gel strength can prevent gas migration and can support its own weight to thereby resist and prevent fall back.
- a cement slurry having a static gel strength, SGS of about 500 pounds per 100 square feet can prevent the percolation of gas through the slurry, i.e., prevent gas migration.
- SGS developed in the cement slurry can prevent fall back due to resistance of the slurry to slide tangentially against the walls of the pipe or bore hole.
- a slurry used in primary cementing should develop a sufficient static gel strength as quickly as possible.
- the time to develop 500 SGS is preferably in the range of from about 15 minutes to about 45 minutes after the slurry has been positioned as desired in the annulus. A more preferred transition time is in the range of from about 20 minutes to about 40 minutes to develop 500 SGS.
- a slurry of hydraulic cement in water is said to be a thixotropic cement. Accordingly, by this definition, the cement slurry of this invention is a thixotropic cement.
- a slurry of hydraulic cement in water to be useful in primary cementing must have the property of remaining sufficiently fluid for the time required to place the slurry in the desired position in the annulus.
- This time referred to as pumping time and also as thickening time, is measured substantially from the time of preparation of the slurry to the time when the slurry has developed sufficient consistency to resist an applied torque.
- thickening time informs an operator of the amount of time available to pump the volume of slurry required to be placed into the desired location.
- a pumping time in the range of from about 3 to about 6 hours is considered by persons skilled in the art as an adequate pumping time for a slurry of hydraulic cement in water.
- thickening time is specifically defined as the time required for a slurry to develop 70 Bearden units of slurry consistence or more simply 70 Bc. The measurement of thickening time is described in Section 8, "Specification for Materials and Testing for Well Cements," API Specification 10 (SPEC 10), Fifth Edition, Jul. 1, 1990, which is incorporated herein by reference.
- Transition time, thickening time, WOC and compressive strength development of a slurry of hydraulic cement in water are all influenced by a number of factors including, the salt content of the mixing water, the quantity of mixing water, the cement itself and the temperature to which the slurry is exposed while hardening.
- Example I To thus demonstrate the effect of the sodium aluminate additive, please refer to Example I, below, wherein several slurries of approximately the same density, same quantity and type of cement and same quantity and type of deaerating agent are employed. The slurries essentially differ with respect to the concentrations of sodium chloride and sodium aluminate. Mixing water is varied to maintain density. A low temperature, 91° F., is employed in the determination of transition time and thickening time and a temperature of 110° F. is employed to determine initial set, WOC and 24 hour compressive strength. Both of these temperatures would be expected to produce a retarding effect upon the development of the above properties.
- Tables 1A and 1B demonstrate the effect on these properties produced by increasing salt concentration wherein Slurry 1 has no salt and Slurry 5 is salt saturated with respect to mixing water.
- Tables 2A and 2B demonstrate the effects on the above properties by the addition of various quantities of sodium aluminate to the slurries described in Table 1A. Notice the somewhat erratic results shown in Table 1B where no aluminate is present and compare these with the more uniform results shown in Table 2B produced by the addition of sodium aluminate. Compare Tables 1B and 2B and notice, in particular, the marked acceleration of transition time in both fresh water and salt water, as well as the adjustment of thickening times to the desired values referred to above; both enhancements are produced by the addition of sodium aluminate.
- the concentration of aluminate should be in the range of from about 0.4 to about 6.0, preferably from about 0.8 to about 3.0 and still more preferably in the range of from about 1.0 to about 2.0 weight parts sodium aluminate per 100 weight parts of hydraulic cement in the slurry.
- Ten slurries comprising hydraulic cement in water were prepared for testing. Each slurry was formulated to produce a density of about 15.6 to about 15.7 pounds per gallon.
- the specific hydraulic cement employed in each slurry was API Class H, as manufactured by Lonestar Cement Company, and mixing water was that available from the tap in Duncan, Oklahoma.
- Each slurry included a defoaming agent to eliminate air entrainment.
- the agent was a commercially available material known as D-AIR 1 which is polypropylene glycol deposited on diatomaceoces earth.
- Sodium chloride was present in eight of the slurries in concentrations of 6 percent, 12 percent, 18 percent and 37.2 percent salt by weight of water in the slurry.
- the SGS Agent a water solution of sodium aluminate, was present in five of the slurries.
- the sodium aluminate concentration in the solution was about 35 percent by weight and the solution had a specific gravity of about 1.45.
- the solution also included a small quantity of sodium hydroxide and had a pH of 14.0.
- sodium aluminate is the specific additive employed herein to improve the thixotropic property of a slurry of hydraulic cement in water as well as to improve the various other properties previously mentioned.
- any of the well known alkali metal aluminates can be utilized in the amounts mentioned above to achieve comparable results.
- the aluminate additive useful herein can be used in the undiluted (dry) condition.
- concentration ranges and ratio ranges recited above are based on aluminate in undiluted solid form.
- One such useful solution contains about 35 percent by weight sodium aluminate and 65 percent by weight water and sufficient sodium hydroxide to adjust the pH to a value of about 14.
- water solutions of aluminate useful herein can contain in the range of from about 30 percent to about 40 percent aluminate by weight of solution. Based upon the concentration ranges set out previously such water solutions can be present in a slurry of hydraulic cement in water in the range of from about 0.67 percent to about 15 percent solution by weight of cement.
- the aluminate solution is preferably present in the range of from about 1 percent to about 6 percent and still more preferably in the range of about 2 percent to about 3 percent aluminate solution by weight of cement.
- the bridging agent is believed to be the ionic aluminate chains which occur in the totally ionic, high pH, aluminate solution described herein. Accordingly, the currently preferred method of introducing the aluminate into the slurry is by means of a high pH, water solution thereof such as that described herein.
- hydroaulic cement as used herein means all inorganic cementitious materials of known type which comprise compounds of calcium, aluminum, silicon, oxygen and/or sulfur which exhibit “hydraulic activity”.
- Hydraulic activity as used herein means the chemical nature of material to set and harden, upon being mixed with water, without contact with the atmosphere e.g. the ability to harden under water) due to the interaction of the constituents of the material rather than by evaporation of the water.
- Cements of this type include common Portland cements, fast setting or extra fast setting, sulfate resistant cements, modified cement, alumina cements, high alumina cement, calcium aluminate cements, and cements which contain secondary components such as fly ash, pozzalona and the like.
- Portland cements are classified by the American Society of Testing Materials (ASTM) into five major types identified by Roman Numerals I, II, III, IV and V and by the American Petroleum Institute into at least 9 categories identified by the letters A, B, C, D, E, F, G, H and J. The classifications are based on chemical compositions and physical properties.
- Section 2 refers to Section 2 of the above cited API Spec. 10 for a further discussion of API cements. Section 2 is incorporated herein by reference.
- the quantity of water utilized to mix with the hydraulic cement must be in an amount sufficient to fully satisfy the potential hydraulic activity of the cement. Such values are specified in Section 5 of the above cited API Spec. 10 which is incorporated herein by reference. In general, however, the quantity of water to be used is in the range of from about 35 to about 60 weight parts water per 100 weight parts of cement.
- Cement slurries particularly useful herein which include the aluminate additive of this invention can have a wide range of densities.
- Particularly preferred slurries have densities in the range of from about 11.5 to about 22.0 and preferably about 15 to 16 lb. slurry per gallon slurry.
- Cement slurries containing the aluminate additive of this invention exhibit thixotropic properties, as above defined, and aid in obtaining early compressive strength at setting temperatures in the range of from about 40° F to about 180° F.
- Salt is often used in cement during oil field primary cementing operations.
- the use of salt in the cement slurry provides several advantages. First, salt containing cement slurries bond more firmly to salt and shale sections often found in subterranean formations. Second, when salt is present in the cement slurry in sufficiently large quantities, it assists in the prevention of shale sections from sluffing, bridging between formation zones, and washing out, and salt formations from leeching or washing out.
- salt particularly refers to sodium chloride and to solutions which include sodium chloride as a primary ingredient, such as sea salt.
- the term also particularly includes potassium chloride and the alkali metal halides in general.
- Slurries of hydraulic cement in water were prepared and tested to determine transition time and thickening time.
- the slurries varied in density and included both fresh water, salt water and sea water. Certain of the slurries included Halad fluid loss additive and HR-5 retardant.
- the slurry recipes are contained in Table 3A below and the Test results are contained in Table 3B below.
- Halad is a registered trademark of Halliburton Company. It is used to designate a series of products referred to as fluid loss additives. Additives of this type prevent the loss of the aqueous phase of the cementing slurry to subterranean formations. In the absence of fluid loss additives, it is possible that the slurry density could increase to the point where circulation pressures become unacceptably high, slurry response properties are adversely effected, and/or formation of a bridge in the annulus results in a premature job termination. Additives of this type are typically cellulose derivatives, mixtures of cellulose derivatives and other components, or synthetic polymers. Additives based on cellulose derivatives are described in U.S. Pat. No. 4,455,169, while additives based on synthetic polymers are described in U.S. Pat. No. 4,555,269.
- HR-5 is a registered trademark of Halliburton Company. It is a refined sodium lignosulfonate employed as a cement hydration retardant. Products of this type are described in U.S. Pat. No. 4,047,567.
Abstract
A composition for and method of performing primary cementing operations is disclosed. The method comprises the use of a water slurry of a thixotropic cementing composition which rapidly develops sufficient static gel strength to reduce if not eliminate annular gas migration.
Description
1. Technical Field of the Invention
This invention relates to the construction of wells. The invention further relates to primary cementing operations involved in the construction of wells penetrating subterranean formations. This invention still further relates to hydraulic cementing compositions and methods of using them to perform primary cementing operations.
2. Problems Solved
During the construction of a well, such as an oil and gas well, it is known in the art to place a volume of a water slurry of a hydraulic cement into the annular space defined between the walls of the borehole penetrating a subterranean formation and the exterior surface of the well casing suspended therein. It is also known in the art to place the slurry into the annular space defined between the walls of concentric pipes--such as a well casing and a liner--suspended in the borehole. Subsequent to placement of the slurry further construction operations in the borehole, such as drilling, are suspended for a time sufficient to permit the slurry to set, that is to solidify, to thereby form a mass of hardened cement in the annulus. The mass of hardened cement is referred to as the sheath. The cementing procedure thus described leading to and terminating with the construction of the sheath is referred to as primary cementing. The objectives of the sheath are to provide physical support and positioning of the casing in the borehole; to bond the casing to the walls of the borehole; to prevent the movement of fluid (liquid or gas) between formations penetrated by the borehole; and to prevent fluid from completely escaping the well at the surface of the earth.
In addition to the above objectives, it is desirable that the slurry set and develop sufficient compressive strength in as short a period of time as possible after placement thereof in order to avoid excessive delay in performing further well construction operations. It is a generally accepted standard in the well drilling industry that the compressive strength of set hydraulic cement in the sheath preferably shall be at least about 500 pounds per square inch before further operations may be conducted, wherein the time required to develop the strength, measured from the completion of the placement of the slurry in the annulus, preferably shall not exceed about 24 hours. This time delay is referred to in the art as waiting-on-cement or simply as WOC.
When a slurry of hydraulic cement is positioned in the desired location in the annulus, the slurry movement rapidly changes from a moving, or dynamic, condition when being placed, to a resting, or static, condition after being placed. The slurry, when in the static condition and not yet set, must immediately resist movement of formation fluid through the slurry. Such movement, which is generally gas moving under the influence of formation pressure, is referred to as annular gas migration or simply as gas migration. In addition, the slurry itself, when in the static condition, must resist any movement by it into subterranean zones with which the slurry is in communication. Such movement is generally due to the influence of hydrostatic pressure of the slurry on the zone and is referred to as fall back because the height of slurry in the annulus is reduced by the quantity of slurry penetrating the zone.
Gas migration in the slurry leads directly to gas migration in the sheath, and can cause poor bonding of cement, casing and borehole. Fall back can result in a reduction of the quantity of sheath required to position and support the casing in the borehole. Accordingly, gas migration through the slurry and fall back of the slurry can frustrate the stated objectives of the sheath.
This invention provides a composition for and a method of cementing a casing in a borehole whereby gas migration and fall back ar substantially reduced if not eliminated.
It has been discovered that addition of an effective amount of sodium aluminate to a slurry of hydraulic cement in water can substantially improve the static gel strength of the slurry and particularly the rate of development thereof whereby gas migration and fall back are substantially reduced if not eliminated.
The expression, static gel strength, as used herein, generally refers to the capacity of a fluid under static conditions to resist being moved by a shear force or simply as shear resistance. Where the fluid under consideration is a slurry of a hydraulic cement in water the expression more specifically refers to the resistance to movement, or internal rigidity, developed by the slurry when the slurry is not in motion.
A slurry having a sufficiently high static gel strength can prevent gas migration and can support its own weight to thereby resist and prevent fall back.
It is believed that a cement slurry having a static gel strength, SGS, of about 500 pounds per 100 square feet can prevent the percolation of gas through the slurry, i.e., prevent gas migration. Also, SGS developed in the cement slurry can prevent fall back due to resistance of the slurry to slide tangentially against the walls of the pipe or bore hole. Accordingly, a slurry used in primary cementing should develop a sufficient static gel strength as quickly as possible. The time to develop 500 SGS, referred to herein as transition time, is preferably in the range of from about 15 minutes to about 45 minutes after the slurry has been positioned as desired in the annulus. A more preferred transition time is in the range of from about 20 minutes to about 40 minutes to develop 500 SGS. A slurry of hydraulic cement in water, either alone or having admixed therewith the usual cementing additives such as defoamers, fluid loss agents and set retarding agents, which develops 500 SGS within a reasonable period of time is said to be a thixotropic cement. Accordingly, by this definition, the cement slurry of this invention is a thixotropic cement.
A slurry of hydraulic cement in water to be useful in primary cementing must have the property of remaining sufficiently fluid for the time required to place the slurry in the desired position in the annulus. This time, referred to as pumping time and also as thickening time, is measured substantially from the time of preparation of the slurry to the time when the slurry has developed sufficient consistency to resist an applied torque. In more practical terms, thickening time informs an operator of the amount of time available to pump the volume of slurry required to be placed into the desired location. A pumping time in the range of from about 3 to about 6 hours is considered by persons skilled in the art as an adequate pumping time for a slurry of hydraulic cement in water.
As used herein, thickening time is specifically defined as the time required for a slurry to develop 70 Bearden units of slurry consistence or more simply 70 Bc. The measurement of thickening time is described in Section 8, "Specification for Materials and Testing for Well Cements," API Specification 10 (SPEC 10), Fifth Edition, Jul. 1, 1990, which is incorporated herein by reference.
Transition time, thickening time, WOC and compressive strength development of a slurry of hydraulic cement in water are all influenced by a number of factors including, the salt content of the mixing water, the quantity of mixing water, the cement itself and the temperature to which the slurry is exposed while hardening.
In general by decreasing slurry density, such as by increasing the quantity of mixing water, strength development is retarded, transition time increases, WOC increases and compressive strength decreases. Similar results are obtained by decreasing setting temperature environment to values of about 180° F. or lower. Addition of salt, such as sodium chloride, to the mixing water produces a variable result, depending upon the amount of salt. That is, low concentrations of salt seem to produce an acceleration effect while higher concentrations seem to produce a retardation effect.
The various effects alluded to above can be offset by adding an effective amount of sodium aluminate to a given slurry. In this regard, with respect to a given slurry, transition time, thickening time, WOC and initial set can be accelerated and compressive strength can be increased by adding thereto an effective amount of sodium aluminate.
To thus demonstrate the effect of the sodium aluminate additive, please refer to Example I, below, wherein several slurries of approximately the same density, same quantity and type of cement and same quantity and type of deaerating agent are employed. The slurries essentially differ with respect to the concentrations of sodium chloride and sodium aluminate. Mixing water is varied to maintain density. A low temperature, 91° F., is employed in the determination of transition time and thickening time and a temperature of 110° F. is employed to determine initial set, WOC and 24 hour compressive strength. Both of these temperatures would be expected to produce a retarding effect upon the development of the above properties.
Tables 1A and 1B demonstrate the effect on these properties produced by increasing salt concentration wherein Slurry 1 has no salt and Slurry 5 is salt saturated with respect to mixing water. Tables 2A and 2B demonstrate the effects on the above properties by the addition of various quantities of sodium aluminate to the slurries described in Table 1A. Notice the somewhat erratic results shown in Table 1B where no aluminate is present and compare these with the more uniform results shown in Table 2B produced by the addition of sodium aluminate. Compare Tables 1B and 2B and notice, in particular, the marked acceleration of transition time in both fresh water and salt water, as well as the adjustment of thickening times to the desired values referred to above; both enhancements are produced by the addition of sodium aluminate. In addition, the development of 24 hour compressive strength is rendered more uniform and WOC times are all within acceptable limits. The results achieved are all considered quite acceptable with the exception of those for salt saturated water (37.2% by weight). Accordingly, at salt concentrations in the range of 0 percent to about 18 percent by weight of water improvement of the various properties can be produced.
It is believed that satisfactory results, such as those shown in Table 2B, can be obtained, with respect to a slurry of any given density having a salt concentration in the range of from 0 up to about 18% by weight of water, by adjusting the amount of sodium aluminate relative to the amount of salt to values in the range of from about 0.02 to about 0.35 weight parts aluminate per weight part of salt in the slurry. Where salt is not present in the slurry, it is believed that the concentration of aluminate should be in the range of from about 0.2 to about 2.0, preferably from about 0.4 to about 1.0 and still more preferably from about 0.6 to about 0.8 weight parts sodium aluminate per 100 weight parts of hydraulic cement in the slurry. Where salt is present in the slurry, it is believed that the concentration of aluminate should be in the range of from about 0.4 to about 6.0, preferably from about 0.8 to about 3.0 and still more preferably in the range of from about 1.0 to about 2.0 weight parts sodium aluminate per 100 weight parts of hydraulic cement in the slurry.
Ten slurries comprising hydraulic cement in water were prepared for testing. Each slurry was formulated to produce a density of about 15.6 to about 15.7 pounds per gallon. The specific hydraulic cement employed in each slurry was API Class H, as manufactured by Lonestar Cement Company, and mixing water was that available from the tap in Duncan, Oklahoma. Each slurry included a defoaming agent to eliminate air entrainment. The agent was a commercially available material known as D-AIR 1 which is polypropylene glycol deposited on diatomaceoces earth. Sodium chloride was present in eight of the slurries in concentrations of 6 percent, 12 percent, 18 percent and 37.2 percent salt by weight of water in the slurry. The SGS Agent, a water solution of sodium aluminate, was present in five of the slurries. The sodium aluminate concentration in the solution was about 35 percent by weight and the solution had a specific gravity of about 1.45. The solution also included a small quantity of sodium hydroxide and had a pH of 14.0.
The specific recipe for each slurry is set out in Table 1A and Table 2A, below.
The test conditions and results are reported in Table 1B and Table 2B, below.
TABLE 1a
______________________________________
Recipe
Slurry
1 2 3 4 5
Weight
Weight Weight Weight
Weight
Parts Parts Parts Parts Parts
______________________________________
Water.sup.1 45.3 47.7 48.9 50.1 52.7
Cement 100 100 100 100 100
Defoamer 0.25 0.25 0.25 0.25 0.25
Salt 0 2.86 5.87 9.01 19.6
SGS Agent.sup.2
0 0 0 0 0
Slurry Density.sup.3
15.7 15.6 15.6 15.6 15.6
##STR1## -- 0 0 0 0
______________________________________
.sup.1 Total water including mixing water and water in SGS Agent
.sup.2 Active ingredient only, does not include water
.sup.3 Slurry density, lb/gal
TABLE 1B
______________________________________
RESULTS
TIME, HR:MIN
Initial Trans- Comp. Str..sup.2
Slurry
Set.sup.2
WOC.sup.2
ition.sup.1
Thickening.sup.1
24 HR
No. 50 PSI 500 PSI 500 SGS
70 BC PSI
______________________________________
1 3:08 7:23 1:40 10:20 2000
2 3:15 14:30 1:00 4:47 680
3 1:28 4:45 1:13 7:45 1600
4 2:54 45:38 1:08 21:31 250
5 8:08 25:50 2:07 25:30+ 410
______________________________________
.sup.1 Thickening time and transition time determined at 91° F. an
1500 psi
.sup.2 Initial Set, WOC and 24 hour compressive strength determined at
110° F. and 3000 psi in ultrasonic cement analyzer (U.S. Pat. No.
4,259,868)
TABLE 2a
______________________________________
Recipe
Slurry
1 2 3 4 5
Weight
Weight Weight Weight
Weight
Parts Parts Parts Parts Parts
______________________________________
Water.sup.1 45.8 48.3 49.6 51.0 55.5
Cement 100 100 100 100 100
Defoamer 0.25 0.25 0.25 0.25 0.25
Salt 0 2.9 5.94 9.19 20.65
SGS Agent.sup.2
0.54 0.67 0.68 0.9 2.70
Slurry Density.sup.3
15.7 15.6 15.6 15.6 15.6
##STR2## 0 0.232 0.114 0.098 0.131
______________________________________
.sup.1 Total water including mixing water and water in SGS Agent
.sup.2 Active ingredient only, does not include water
.sup.3 Slurry density, lb/gal
TABLE 2B
______________________________________
Results
Time, Hr:Min
Initial Trans- Comp. Str..sup.2
Slurry
Set.sup.2
WOC.sup.2
ition.sup.1
Thickening.sup.1
24 HR
No. 50 psi 500 psi 500 SGS
70 Bc psi
______________________________________
1 2:09 4:55 0:43 5:05 2300
2 2:08 5:55 0:59 2:56 1750
3 2:13 5:35 0:29 3:34 1750
4 2:40 7:24 0:54 5:16 1250
5 9:46 >25:50 1:05 14:17+ 310
______________________________________
.sup.1 Thickening Time and Transition Time determined at 91° F. an
1500 psi
.sup.2 Initial Set, WOC and 24 Hour Compressive Strength determined at
110° F. and 3000 psi in Ultrasonic Cement Analyzer (U.S. Pat. No.
4,259,868)
As mentioned above sodium aluminate is the specific additive employed herein to improve the thixotropic property of a slurry of hydraulic cement in water as well as to improve the various other properties previously mentioned. However, it is believed that any of the well known alkali metal aluminates can be utilized in the amounts mentioned above to achieve comparable results.
The aluminate additive useful herein can be used in the undiluted (dry) condition. In fact, the concentration ranges and ratio ranges recited above are based on aluminate in undiluted solid form. However, for matters of convenience of use, it is advantageous to add the aluminate as a water solution. One such useful solution contains about 35 percent by weight sodium aluminate and 65 percent by weight water and sufficient sodium hydroxide to adjust the pH to a value of about 14.
In a broader sense, water solutions of aluminate useful herein can contain in the range of from about 30 percent to about 40 percent aluminate by weight of solution. Based upon the concentration ranges set out previously such water solutions can be present in a slurry of hydraulic cement in water in the range of from about 0.67 percent to about 15 percent solution by weight of cement. The aluminate solution is preferably present in the range of from about 1 percent to about 6 percent and still more preferably in the range of about 2 percent to about 3 percent aluminate solution by weight of cement.
It is not the desire herein to be bound by a particular theory of operation or of attained result; however, it is believed that the majority of the thixotropic response observed herein is a result of bridging between initially hydrated cement particles wherein the bridging agent is believed to be the ionic aluminate chains which occur in the totally ionic, high pH, aluminate solution described herein. Accordingly, the currently preferred method of introducing the aluminate into the slurry is by means of a high pH, water solution thereof such as that described herein.
The term "hydraulic cement" as used herein means all inorganic cementitious materials of known type which comprise compounds of calcium, aluminum, silicon, oxygen and/or sulfur which exhibit "hydraulic activity". "Hydraulic activity" as used herein means the chemical nature of material to set and harden, upon being mixed with water, without contact with the atmosphere e.g. the ability to harden under water) due to the interaction of the constituents of the material rather than by evaporation of the water.
Cements of this type include common Portland cements, fast setting or extra fast setting, sulfate resistant cements, modified cement, alumina cements, high alumina cement, calcium aluminate cements, and cements which contain secondary components such as fly ash, pozzalona and the like.
Portland cements are classified by the American Society of Testing Materials (ASTM) into five major types identified by Roman Numerals I, II, III, IV and V and by the American Petroleum Institute into at least 9 categories identified by the letters A, B, C, D, E, F, G, H and J. The classifications are based on chemical compositions and physical properties.
In this regard, refer to Section 2 of the above cited API Spec. 10 for a further discussion of API cements. Section 2 is incorporated herein by reference.
The quantity of water utilized to mix with the hydraulic cement must be in an amount sufficient to fully satisfy the potential hydraulic activity of the cement. Such values are specified in Section 5 of the above cited API Spec. 10 which is incorporated herein by reference. In general, however, the quantity of water to be used is in the range of from about 35 to about 60 weight parts water per 100 weight parts of cement.
Cement slurries particularly useful herein which include the aluminate additive of this invention, can have a wide range of densities. Particularly preferred slurries have densities in the range of from about 11.5 to about 22.0 and preferably about 15 to 16 lb. slurry per gallon slurry.
Cement slurries containing the aluminate additive of this invention exhibit thixotropic properties, as above defined, and aid in obtaining early compressive strength at setting temperatures in the range of from about 40° F to about 180° F.
Salt is often used in cement during oil field primary cementing operations. The use of salt in the cement slurry provides several advantages. First, salt containing cement slurries bond more firmly to salt and shale sections often found in subterranean formations. Second, when salt is present in the cement slurry in sufficiently large quantities, it assists in the prevention of shale sections from sluffing, bridging between formation zones, and washing out, and salt formations from leeching or washing out.
As used herein, the term salt particularly refers to sodium chloride and to solutions which include sodium chloride as a primary ingredient, such as sea salt. The term also particularly includes potassium chloride and the alkali metal halides in general.
Slurries of hydraulic cement in water were prepared and tested to determine transition time and thickening time. The slurries varied in density and included both fresh water, salt water and sea water. Certain of the slurries included Halad fluid loss additive and HR-5 retardant.
The slurry recipes are contained in Table 3A below and the Test results are contained in Table 3B below.
Halad is a registered trademark of Halliburton Company. It is used to designate a series of products referred to as fluid loss additives. Additives of this type prevent the loss of the aqueous phase of the cementing slurry to subterranean formations. In the absence of fluid loss additives, it is possible that the slurry density could increase to the point where circulation pressures become unacceptably high, slurry response properties are adversely effected, and/or formation of a bridge in the annulus results in a premature job termination. Additives of this type are typically cellulose derivatives, mixtures of cellulose derivatives and other components, or synthetic polymers. Additives based on cellulose derivatives are described in U.S. Pat. No. 4,455,169, while additives based on synthetic polymers are described in U.S. Pat. No. 4,555,269.
HR-5 is a registered trademark of Halliburton Company. It is a refined sodium lignosulfonate employed as a cement hydration retardant. Products of this type are described in U.S. Pat. No. 4,047,567.
U.S. Pat. Nos. 4,047,567, 4,455,169 and 4,555,269 are incorporated herein by reference.
TABLE 3A
__________________________________________________________________________
Recipe
0.25% Defoamer.sup.4
SGS Sea Fresh
Slurry
Cement
Agent.sup.3
KCl
NaCl
Water
Water
Density
No. Type (gal/sk)
(%).sup.5
(%).sup.5
(gal/sk)
(gal/sk)
(lb/gal)
__________________________________________________________________________
1 LeHarve.sup.1
0.05 0.0
0.0 5.36 0.00 15.6
2 LeHarve
0.10 0.0
0.0 5.33 0.00 15.6
3 LeHarve
0.15 0.0
0.0 5.31 0.00 15.6
4 LeHarve
0.10 0.0
0.0 6.17 0.00 15.0
5 LeHarve
0.08 0.0
0.0 7.98 0.00 14.0
6 LeHarve
0.35 0.0
0.0 10.54
0.00 13.0
7 LeHarve
0.30 0.0
0.0 12.37
0.00 12.5
8 LeHarve
0.15 0.0
0.0 12.39
0.00 12.5
9 LeHarve
0.15 0.0
0.0 12.39
0.00 12.5
10 LeHarve
0.20 0.0
0.0 12.38
0.00 12.5
11 LeHarve
0.15 3.0
0.0 0.00 5.21 15.6
12 LeHarve
0.25 3.0
0.0 0.00 7.76 14.0
13 LSH.sup.2
0.50 0.0
6 0.00 12.57
12.5
14 LSH 0.75 0.0
6 0.00 12.56
12.5
15 LSH 1.00 0.0
6 0.00 12.55
12.5
16 LSH 0.15 0.0
12 0.00 5.45 15.6
17 LSH 0.50 0.0
12 0.00 13.43
12.5
18 LSH 1.00 0.0
12 0.00 13.45
12.5
19 LSH 1.15 0.0
12 0.00 13.45
12.5
20 LSH 1.25 0.0
12 0.00 13.45
12.5
21 LSH 1.50 0.0
12 0.00 12.95
12.6
22 LSH 2.00 0.0
12 0.00 11.50
12.5
23 LSH 0.20 0.0
18 0.00 5.57 15.6
24 LSH 0.30 0.0
37.2
0.00 5.82 15.6
25 LSH 0.40 0.0
37.2
0.00 5.78 15.6
26 LSH 0.50 0.0
37.2
0.00 5.74 15.6
27 LSH 0.60 0.0
37.2
0.00 5.70 15.6
28 LSH 1.00 0.0
37.2
0.00 5.53 15.6
__________________________________________________________________________
.sup.1 LeHarve is API Class H Cement as manufactured by LaFarge Corp.,
LaFarge, France
.sup.2 LSH is API Class H Cement as manufactured by Lonestar Industries,
Inc., Greenwich, Conn.
.sup.3 The SGS Agent is sodium aluminate in a 35% by weight water solutio
having a specific gravity of 1.45 and a pH of 14.0. The concentration of
agent is expressed in gallons per 94lb. sack of cement
.sup.4 The defoamer is a commercially available material known as DAIR 1
.sup.5 Percent by weight of water
TABLE 3B
______________________________________
Results
Transition
Thickening
Slurry Cement Time Time
No. Type (Min) (Hr:Min)
______________________________________
1 LeHarve 30 3:23
2 LeHarve 10 --
3 LeHarve 22 --
4 LeHarve 20 --
5 LeHarve 27 4:35
6 LeHarve 12 --
7 LeHarve 8 --
8 LeHarve 32 --
9 LeHarve 23 6:30
10 LeHarve 30 3:23
11 LeHarve 26 2:54
12 LeHarve 18 12:15
13 LSH -- 22:50+
14 LSH -- 22:00+
15 LSH -- 7:00+
16 LSH 29 3:34
17 LSH -- 22:39
18 LSH -- 23:30
19 LSH -- 8:06
20 LSH -- 0:42
21 LSH -- 0:34
22 LSH -- 0:31
23 LSH 26 3:30
24 LSH -- 17:18+
25 LSH -- 16:48+
26 LSH -- 15:25+
27 LSH -- 14:17+
28 LSH -- 32:00+
______________________________________
Claims (21)
1. A thixotropic cementing composition consisting essentially of hydraulic cement, water, an alkali metal aluminate and an alkali metal halide:
wherein, said aluminate is present in said composition in an amount in the range of from about 0.2 to about 6.0 percent aluminate by weight of said hydraulic cement; said water is present in said composition in amount in the range of from about 35 to about 60 percent water by weight of said hydraulic cement; and said alkali metal halide is present in said composition in an amount in the range of from about a trace up to about 18 percent of said halide by weight water.
2. The composition of claim 1 wherein said alkali metal aluminate is sodium aluminate.
3. The composition of claim 2 wherein said alkali metal halide is sodium chloride.
4. The composition of claim 3 wherein said aluminate is present in a water solution thereof in the amount in the range of from about 30 percent to about 40 percent aluminate by weight of said solution and said solution is present in said composition in an amount in the range of from about 0.67 percent to about 15 percent solution by weight of said hydraulic cement.
5. The composition of claim 4 wherein said hydraulic cement is Portland cement.
6. A method of increasing the thixotropic nature of a slurry consisting essentially of hydraulic cement in water wherein said water includes an alkali metal halide present therein in an amount in the range of from about 0 up to about 18 percent halide by weight of said water, said method consisting essentially of adding to said slurry an effective amount of an alkali metal aluminate.
7. The method of claim 6 wherein said water is present in said slurry in an amount in the range of from about 35 percent to about 60 percent water by weight of said hydraulic cement.
8. The method of claim 7 wherein said aluminate is added to said slurry in an amount in the range of from about 0.2 percent to about 6.0 percent aluminate by weight of said hydraulic cement.
9. A method of reducing the time required for a slurry consisting essentially of Portland cement in water to set into a hardened mass wherein said water contains an alkali metal halide dissolved therein in an amount in the range of from about 0 up to about 18 percent halide by weight of said water,
said method consisting essentially of adding to said slurry an effective amount of an alkali metal aluminate.
10. The method of claim 9 wherein said slurry is caused to set at a temperature of up to about 180° F.
11. The method of claim 10 wherein said water is present in said slurry in an amount in the range of from about 35 percent to about 60 percent water by weight of said hydraulic cement.
12. The method of claim 11 wherein said aluminate is added to said slurry in an amount in the range of from about 0.2 percent to about 6.0 percent aluminate by weight of said hydraulic cement.
13. The method of claim 12 wherein said aluminate is added to said slurry in a water solution thereof wherein said aluminate is present in said solution in an amount in the range of from about 30 percent to about 40 percent aluminate by weight of said solution.
14. The method of claim 13 wherein said water solution of said aluminate is added to said slurry in an amount in the range of from about 0.67 percent to about 15 percent solution by weight of said hydraulic cement.
15. A method of reducing gas migration through and fall back of a static slurry consisting essentially of Portland cement in water by accelerating the development of static gel strength of said slurry
wherein said method consists essentially of adding to said slurry an effective amount of an alkali metal aluminate and further
wherein an alkali metal halide is present in said slurry in an amount up to about 18 pounds halide per 100 pounds of water in said slurry.
16. The method of claim 9 wherein said alkali metal aluminate is sodium aluminate and said alkali metal halide is sodium chloride.
17. The method of claim 15 wherein said effective amount of said alkali metal aluminate is in the range of from about 0.2 to about 6.0 percent of said aluminate by weight of said hydraulic cement.
18. The method of claim 17 wherein said water is present in said slurry in the range of from about 35 percent to about 60 percent water by weight of said hydraulic cement.
19. The method of claim 18 wherein said alkali metal aluminate is sodium aluminate and said alkali metal halide is sodium chloride.
20. The method of claim 19 wherein said slurry is maintained in said static condition at a temperature in the range of from about 40° F. to about 180° F.
21. The method of claim 20 wherein said sodium aluminate is added to said slurry in the form of a water solution thereof, wherein said aluminate is present in said solution in the range of from about 30 percent to about 40 percent by weight of said solution, said solution has a pH of about 14 and said solution has a specific gravity of about 1.45.
Priority Applications (7)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US07/718,679 US5151203A (en) | 1991-06-21 | 1991-06-21 | Composition and method for cementing a well |
| CA002316038A CA2316038C (en) | 1991-06-21 | 1992-06-19 | Composition and method for cementing a well |
| NO92922429A NO922429L (en) | 1991-06-21 | 1992-06-19 | COMPOSITION AND PROCEDURE FOR CEMENTATION OF A BROWN |
| CA002438654A CA2438654C (en) | 1991-06-21 | 1992-06-19 | Composition and method for cementing a well |
| CA002071722A CA2071722C (en) | 1991-06-21 | 1992-06-19 | Composition and method for cementing a well |
| EP92305706A EP0519756B1 (en) | 1991-06-21 | 1992-06-22 | Thixotropic well cementing composition |
| DE69214360T DE69214360T2 (en) | 1991-06-21 | 1992-06-22 | Borehole cementing thixotropic composition |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US07/718,679 US5151203A (en) | 1991-06-21 | 1991-06-21 | Composition and method for cementing a well |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| US5151203A true US5151203A (en) | 1992-09-29 |
Family
ID=24887040
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| US07/718,679 Expired - Lifetime US5151203A (en) | 1991-06-21 | 1991-06-21 | Composition and method for cementing a well |
Country Status (5)
| Country | Link |
|---|---|
| US (1) | US5151203A (en) |
| EP (1) | EP0519756B1 (en) |
| CA (1) | CA2071722C (en) |
| DE (1) | DE69214360T2 (en) |
| NO (1) | NO922429L (en) |
Cited By (33)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5322389A (en) * | 1993-03-04 | 1994-06-21 | Conversion Systems, Inc. | Method for transporting a cementitious mixture to an underground space |
| US5549745A (en) * | 1994-10-28 | 1996-08-27 | Indresco Inc. | Non-slumping, pumpable castable and method of applying the same |
| US6153562A (en) * | 1996-09-30 | 2000-11-28 | Schlumberger Technology Corporation | Cementing slurry and method of designing a formulation |
| US6244343B1 (en) | 2000-03-09 | 2001-06-12 | Halliburton Energy Services, Inc. | Cementing in deep water offshore wells |
| US6313055B1 (en) | 1998-08-20 | 2001-11-06 | Harbison-Walker Refractories Company | Refractory castables containing thermal black |
| US6313056B1 (en) | 1998-08-20 | 2001-11-06 | Harbison-Walker Refractories Company | Non-slumping sprayable refractory castables containing thermal black |
| US20040048751A1 (en) * | 2002-08-30 | 2004-03-11 | Bach Dao | Process for controlling gas migration during well cementing |
| US6908508B2 (en) | 2003-06-04 | 2005-06-21 | Halliburton Energy Services, Inc. | Settable fluids and methods for use in subterranean formations |
| US20050155795A1 (en) * | 2004-01-16 | 2005-07-21 | Reddy B. R. | Settable fluids comprising particle-size distribution-adjusting agents and methods of use |
| US20050173117A1 (en) * | 2004-02-10 | 2005-08-11 | Roddy Craig W. | Use of substantially hydrated cement particulates in cementing and subterranean applications |
| US20050230112A1 (en) * | 2004-04-19 | 2005-10-20 | Reddy B R | Sealant compositions comprising colloidally stabilized latex and methods of using the same |
| US20060122071A1 (en) * | 2004-12-08 | 2006-06-08 | Hallbiurton Energy Services, Inc. | Oilwell sealant compositions comprising alkali swellable latex |
| US20060162926A1 (en) * | 2004-02-10 | 2006-07-27 | Halliburton Energy Services, Inc. | Methods of using substantially hydrated cement particulates in subterranean applications |
| US20060166834A1 (en) * | 2004-02-10 | 2006-07-27 | Halliburton Energy Services, Inc. | Subterranean treatment fluids comprising substantially hydrated cement particulates |
| US20060169453A1 (en) * | 2005-02-01 | 2006-08-03 | Savery Mark R | Kickoff plugs comprising a self-degrading cement in subterranean well bores |
| US20060174803A1 (en) * | 2005-02-08 | 2006-08-10 | Caveny William J | Low-density cement compositions, density-reducing additives, and methods of use |
| US20060174804A1 (en) * | 2005-02-08 | 2006-08-10 | Caveny William J | Low-density cement compositions, density-reducing additives, and methods of use |
| US20060272819A1 (en) * | 2004-01-16 | 2006-12-07 | Halliburton Energy Services, Inc. | Methods of preparing settable fluids comprising particle-size distribution-adjusting agents, and associated methods |
| US20070111900A1 (en) * | 2005-11-11 | 2007-05-17 | Reddy B R | Sealant compositions comprising solid latex |
| US20070111901A1 (en) * | 2005-11-11 | 2007-05-17 | Reddy B R | Method of servicing a wellbore with a sealant composition comprising solid latex |
| US7497258B2 (en) | 2005-02-01 | 2009-03-03 | Halliburton Energy Services, Inc. | Methods of isolating zones in subterranean formations using self-degrading cement compositions |
| US20090124522A1 (en) * | 2004-02-10 | 2009-05-14 | Roddy Craig W | Cement Compositions and Methods Utilizing Nano-Hydraulic Cement |
| US20090139719A1 (en) * | 2004-02-10 | 2009-06-04 | Halliburton Energy Services, Inc. | Cement-based particulates and methods of use |
| US20100038084A1 (en) * | 2008-08-14 | 2010-02-18 | Roddy Craig W | Cement Compositions Comprising Aluminum Chloride and Associated Methods |
| US20110147013A1 (en) * | 2009-12-18 | 2011-06-23 | Marion Dewey Kilgore | Retrieval Method For Opposed Slip Type Packers |
| US8476203B2 (en) | 2007-05-10 | 2013-07-02 | Halliburton Energy Services, Inc. | Cement compositions comprising sub-micron alumina and associated methods |
| US8586512B2 (en) | 2007-05-10 | 2013-11-19 | Halliburton Energy Services, Inc. | Cement compositions and methods utilizing nano-clay |
| US8685903B2 (en) | 2007-05-10 | 2014-04-01 | Halliburton Energy Services, Inc. | Lost circulation compositions and associated methods |
| US20140352963A1 (en) * | 2011-06-17 | 2014-12-04 | Amir H. Mahmoudkhani | Powder Defoaming Compositions and Methods of Reducing Gas Entrainment In Fluids |
| US20150246666A1 (en) * | 2014-02-28 | 2015-09-03 | Tramec Sloan, Llc | Modulator valve |
| US9199879B2 (en) | 2007-05-10 | 2015-12-01 | Halliburton Energy Serives, Inc. | Well treatment compositions and methods utilizing nano-particles |
| US9206344B2 (en) | 2007-05-10 | 2015-12-08 | Halliburton Energy Services, Inc. | Sealant compositions and methods utilizing nano-particles |
| US9512351B2 (en) | 2007-05-10 | 2016-12-06 | Halliburton Energy Services, Inc. | Well treatment fluids and methods utilizing nano-particles |
Families Citing this family (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7867954B2 (en) | 2007-10-22 | 2011-01-11 | Sanjel Limited Partnership | Pumice containing compositions for cementing a well |
| DE102019204950A1 (en) * | 2019-04-08 | 2020-10-08 | Robert Bosch Gmbh | Inductive component and method for manufacturing an inductive component |
Citations (20)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US2880096A (en) * | 1954-12-06 | 1959-03-31 | Phillips Petroleum Co | Cement compositions and process of cementing wells |
| US3860070A (en) * | 1973-12-13 | 1975-01-14 | Shell Oil Co | Aluminate-thickened well treating fluid and method of use |
| US3874885A (en) * | 1971-02-11 | 1975-04-01 | Abram Moiseevich Lyass | Method of making foundry moulds and cores |
| US3882938A (en) * | 1972-07-17 | 1975-05-13 | Union Oil Co | Process for recovering oil from heterogeneous reservoirs |
| US3922172A (en) * | 1974-01-07 | 1975-11-25 | Dow Chemical Co | High-alumina cement |
| US3928052A (en) * | 1973-08-13 | 1975-12-23 | Halliburton Co | Methods and compositions for sealing subterranean earth formations |
| US3943996A (en) * | 1974-10-30 | 1976-03-16 | Calgon Corporation | Low fluid loss cementing compositions |
| US4009755A (en) * | 1976-03-17 | 1977-03-01 | Union Oil Company Of California | Selectively controlling the flow of fluids through subterranean formations |
| US4069869A (en) * | 1977-02-11 | 1978-01-24 | Union Oil Company Of California | Plugging high permeability zones of reservoirs having heterogeneous permeability |
| US4124075A (en) * | 1977-12-19 | 1978-11-07 | Mobil Oil Corporation | Use of oil-wetting spacers in cementing against evaporites |
| US4140183A (en) * | 1978-02-13 | 1979-02-20 | Union Oil Company Of California | Micellar flooding process for heterogeneous reservoirs |
| US4354875A (en) * | 1981-10-30 | 1982-10-19 | Diamond Shamrock Corporation | Controlling the curing time of alkali metal silicates using derivatives of glyoxal |
| US4384894A (en) * | 1981-10-30 | 1983-05-24 | Diamond Shamrock Corporation | Composition and process for modifying gelation of alkali metal silicates |
| US4455169A (en) * | 1980-07-14 | 1984-06-19 | Halliburton Company | Salt water cement slurries and water loss reducing additives therefor |
| US4528792A (en) * | 1978-05-30 | 1985-07-16 | Cross Robert C | Anchoring cartridges |
| US4534412A (en) * | 1983-12-09 | 1985-08-13 | Union Oil Company Of California | Continuous permeability reduction in subterranean reservoirs |
| US4707188A (en) * | 1984-06-07 | 1987-11-17 | Daicel Chemical Industries, Ltd. | Cement composition for underwater concreting |
| US4734134A (en) * | 1985-06-14 | 1988-03-29 | Dowell Schlumberger Incorporated | Cement slurries, unaffected by salts of magnesium, for cementing wells traversing salt formations, and related cementing processes |
| US4957555A (en) * | 1989-11-09 | 1990-09-18 | Capitol Aggregates, Inc | Cementing compositions and method |
| US5006177A (en) * | 1983-12-19 | 1991-04-09 | Dowell Schlumberger Incorporated | Process and composition for cementing wells passing through salt formations |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| DE1077595B (en) * | 1952-06-23 | 1960-03-10 | Ruberoidwerke Ag | Process for the production of watertight concrete or cement mortar products |
| FR2314904A1 (en) * | 1975-06-20 | 1977-01-14 | Fritz Ullrich | Rapid setting thixotropic cements and mortars - contg. water soluble thixotropic agent, carbonate ion source, an aluminate and aluminium oxide |
| GB1579356A (en) * | 1977-07-12 | 1980-11-19 | Standard Oil Co | Process and composition for cementing casing in well |
-
1991
- 1991-06-21 US US07/718,679 patent/US5151203A/en not_active Expired - Lifetime
-
1992
- 1992-06-19 NO NO92922429A patent/NO922429L/en unknown
- 1992-06-19 CA CA002071722A patent/CA2071722C/en not_active Expired - Fee Related
- 1992-06-22 EP EP92305706A patent/EP0519756B1/en not_active Expired - Lifetime
- 1992-06-22 DE DE69214360T patent/DE69214360T2/en not_active Expired - Fee Related
Patent Citations (20)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US2880096A (en) * | 1954-12-06 | 1959-03-31 | Phillips Petroleum Co | Cement compositions and process of cementing wells |
| US3874885A (en) * | 1971-02-11 | 1975-04-01 | Abram Moiseevich Lyass | Method of making foundry moulds and cores |
| US3882938A (en) * | 1972-07-17 | 1975-05-13 | Union Oil Co | Process for recovering oil from heterogeneous reservoirs |
| US3928052A (en) * | 1973-08-13 | 1975-12-23 | Halliburton Co | Methods and compositions for sealing subterranean earth formations |
| US3860070A (en) * | 1973-12-13 | 1975-01-14 | Shell Oil Co | Aluminate-thickened well treating fluid and method of use |
| US3922172A (en) * | 1974-01-07 | 1975-11-25 | Dow Chemical Co | High-alumina cement |
| US3943996A (en) * | 1974-10-30 | 1976-03-16 | Calgon Corporation | Low fluid loss cementing compositions |
| US4009755A (en) * | 1976-03-17 | 1977-03-01 | Union Oil Company Of California | Selectively controlling the flow of fluids through subterranean formations |
| US4069869A (en) * | 1977-02-11 | 1978-01-24 | Union Oil Company Of California | Plugging high permeability zones of reservoirs having heterogeneous permeability |
| US4124075A (en) * | 1977-12-19 | 1978-11-07 | Mobil Oil Corporation | Use of oil-wetting spacers in cementing against evaporites |
| US4140183A (en) * | 1978-02-13 | 1979-02-20 | Union Oil Company Of California | Micellar flooding process for heterogeneous reservoirs |
| US4528792A (en) * | 1978-05-30 | 1985-07-16 | Cross Robert C | Anchoring cartridges |
| US4455169A (en) * | 1980-07-14 | 1984-06-19 | Halliburton Company | Salt water cement slurries and water loss reducing additives therefor |
| US4354875A (en) * | 1981-10-30 | 1982-10-19 | Diamond Shamrock Corporation | Controlling the curing time of alkali metal silicates using derivatives of glyoxal |
| US4384894A (en) * | 1981-10-30 | 1983-05-24 | Diamond Shamrock Corporation | Composition and process for modifying gelation of alkali metal silicates |
| US4534412A (en) * | 1983-12-09 | 1985-08-13 | Union Oil Company Of California | Continuous permeability reduction in subterranean reservoirs |
| US5006177A (en) * | 1983-12-19 | 1991-04-09 | Dowell Schlumberger Incorporated | Process and composition for cementing wells passing through salt formations |
| US4707188A (en) * | 1984-06-07 | 1987-11-17 | Daicel Chemical Industries, Ltd. | Cement composition for underwater concreting |
| US4734134A (en) * | 1985-06-14 | 1988-03-29 | Dowell Schlumberger Incorporated | Cement slurries, unaffected by salts of magnesium, for cementing wells traversing salt formations, and related cementing processes |
| US4957555A (en) * | 1989-11-09 | 1990-09-18 | Capitol Aggregates, Inc | Cementing compositions and method |
Non-Patent Citations (6)
| Title |
|---|
| "Annular Gas Flow Theory and Prevention Methods Described New Evaluation for Annular Gas-Flow Potential", Oil & Gas Journal, Dec. 10 & 17, 1984, Sutton, et al. |
| Annular Gas Flow Theory and Prevention Methods Described New Evaluation for Annular Gas Flow Potential , Oil & Gas Journal, Dec. 10 & 17, 1984, Sutton, et al. * |
| Halliburton Services Gas Migration Control Solutions Sep. 1990. * |
| Interrelationship Between Critical Cement Properties and Volume Changes During Cement Setting SPE 20451, Sep. 1990, Sutton, et al. * |
| The Relationship of Thickening Time, Gel Strength and Compressive Strengths of Oil Well Cements SPE 11205, Sep. 1982, Sabins, et al. * |
| Transition Time of Cement Slurries Between the fluid and Set State SPE 9285, Sep. 1980, Sabins, et al. * |
Cited By (66)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5322389A (en) * | 1993-03-04 | 1994-06-21 | Conversion Systems, Inc. | Method for transporting a cementitious mixture to an underground space |
| US5549745A (en) * | 1994-10-28 | 1996-08-27 | Indresco Inc. | Non-slumping, pumpable castable and method of applying the same |
| US6153562A (en) * | 1996-09-30 | 2000-11-28 | Schlumberger Technology Corporation | Cementing slurry and method of designing a formulation |
| US6313055B1 (en) | 1998-08-20 | 2001-11-06 | Harbison-Walker Refractories Company | Refractory castables containing thermal black |
| US6313056B1 (en) | 1998-08-20 | 2001-11-06 | Harbison-Walker Refractories Company | Non-slumping sprayable refractory castables containing thermal black |
| US6395662B1 (en) | 1998-08-20 | 2002-05-28 | Harbison-Walker Refractories Company | Non-slumping sprayable refractory castables containing thermal black |
| US6244343B1 (en) | 2000-03-09 | 2001-06-12 | Halliburton Energy Services, Inc. | Cementing in deep water offshore wells |
| US20040048751A1 (en) * | 2002-08-30 | 2004-03-11 | Bach Dao | Process for controlling gas migration during well cementing |
| US6936574B2 (en) | 2002-08-30 | 2005-08-30 | Halliburton Energy Services, Inc. | Process for controlling gas migration during well cementing |
| US7060129B2 (en) | 2002-08-30 | 2006-06-13 | Halliburton Energy Services, Inc. | Process for controlling gas migration during well cementing |
| US20050160947A1 (en) * | 2002-08-30 | 2005-07-28 | Halliburton Energy Services, Inc. | Process for controlling gas migration during well cementing |
| US6908508B2 (en) | 2003-06-04 | 2005-06-21 | Halliburton Energy Services, Inc. | Settable fluids and methods for use in subterranean formations |
| US20060272819A1 (en) * | 2004-01-16 | 2006-12-07 | Halliburton Energy Services, Inc. | Methods of preparing settable fluids comprising particle-size distribution-adjusting agents, and associated methods |
| US20050155795A1 (en) * | 2004-01-16 | 2005-07-21 | Reddy B. R. | Settable fluids comprising particle-size distribution-adjusting agents and methods of use |
| US7328756B2 (en) | 2004-01-16 | 2008-02-12 | Halliburton Energy Serivces, Inc. | Settable fluids comprising particle-size distribution-adjusting agents and methods of use |
| US20080023200A1 (en) * | 2004-01-16 | 2008-01-31 | Reddy B Raghav | Settable Fluids Comprising Particle-Size Distribution-Adjusting Agents and Methods of Use |
| US20050155763A1 (en) * | 2004-01-16 | 2005-07-21 | Reddy B. R. | Settable fluids comprising particle-size distribution-adjusting agents and methods of use |
| US20090124522A1 (en) * | 2004-02-10 | 2009-05-14 | Roddy Craig W | Cement Compositions and Methods Utilizing Nano-Hydraulic Cement |
| US9512346B2 (en) | 2004-02-10 | 2016-12-06 | Halliburton Energy Services, Inc. | Cement compositions and methods utilizing nano-hydraulic cement |
| US9018147B2 (en) | 2004-02-10 | 2015-04-28 | Halliburton Energy Services, Inc. | Cement-based particulates and methods of use |
| US7086466B2 (en) * | 2004-02-10 | 2006-08-08 | Halliburton Energy Services, Inc. | Use of substantially hydrated cement particulates in drilling and subterranean applications |
| US20050173117A1 (en) * | 2004-02-10 | 2005-08-11 | Roddy Craig W. | Use of substantially hydrated cement particulates in cementing and subterranean applications |
| US8183186B2 (en) | 2004-02-10 | 2012-05-22 | Halliburton Energy Services, Inc. | Cement-based particulates and methods of use |
| US20060162926A1 (en) * | 2004-02-10 | 2006-07-27 | Halliburton Energy Services, Inc. | Methods of using substantially hydrated cement particulates in subterranean applications |
| US20090139719A1 (en) * | 2004-02-10 | 2009-06-04 | Halliburton Energy Services, Inc. | Cement-based particulates and methods of use |
| US7341104B2 (en) | 2004-02-10 | 2008-03-11 | Halliburton Energy Services, Inc. | Methods of using substantially hydrated cement particulates in subterranean applications |
| US20060166834A1 (en) * | 2004-02-10 | 2006-07-27 | Halliburton Energy Services, Inc. | Subterranean treatment fluids comprising substantially hydrated cement particulates |
| US20070287639A1 (en) * | 2004-04-19 | 2007-12-13 | Halliburton Energy Services, Inc. | Sealant compositions comprising colloidally stabilized latex and methods of using the same |
| US20050230112A1 (en) * | 2004-04-19 | 2005-10-20 | Reddy B R | Sealant compositions comprising colloidally stabilized latex and methods of using the same |
| US7607483B2 (en) | 2004-04-19 | 2009-10-27 | Halliburton Energy Services, Inc. | Sealant compositions comprising colloidally stabilized latex and methods of using the same |
| US8062999B2 (en) | 2004-04-19 | 2011-11-22 | Halliburton Energy Services Inc. | Sealant compositions comprising colloidally stabilized latex and methods of using the same |
| US8383558B2 (en) | 2004-12-08 | 2013-02-26 | Halliburton Energy Services, Inc. | Oilwell sealant compositions comprising alkali swellable latex |
| US20100035772A1 (en) * | 2004-12-08 | 2010-02-11 | Halliburton Energy Services, Inc. | Sealant compositions comprising solid latex |
| US8100180B2 (en) | 2004-12-08 | 2012-01-24 | Halliburton Energy Services Inc. | Method of servicing a wellbore with a sealant composition comprising solid latex |
| US20100116497A1 (en) * | 2004-12-08 | 2010-05-13 | Halliburton Energy Services, Inc. | Method of servicing a wellbore with a sealant composition comprising solid latex |
| US20090137431A1 (en) * | 2004-12-08 | 2009-05-28 | Halliburton Energy Services, Inc. | Oilwell sealant compositions comprising alkali swellable latex |
| US7488705B2 (en) | 2004-12-08 | 2009-02-10 | Halliburton Energy Services, Inc. | Oilwell sealant compositions comprising alkali swellable latex |
| US20060122071A1 (en) * | 2004-12-08 | 2006-06-08 | Hallbiurton Energy Services, Inc. | Oilwell sealant compositions comprising alkali swellable latex |
| US7637319B2 (en) | 2005-02-01 | 2009-12-29 | Halliburton Energy Services, Inc, | Kickoff plugs comprising a self-degrading cement in subterranean well bores |
| US7640985B2 (en) | 2005-02-01 | 2010-01-05 | Halliburton Energy Services, Inc. | Methods of directional drilling and forming kickoff plugs using self-degrading cement in subterranean well bores |
| US20060169453A1 (en) * | 2005-02-01 | 2006-08-03 | Savery Mark R | Kickoff plugs comprising a self-degrading cement in subterranean well bores |
| US7497258B2 (en) | 2005-02-01 | 2009-03-03 | Halliburton Energy Services, Inc. | Methods of isolating zones in subterranean formations using self-degrading cement compositions |
| US20060174803A1 (en) * | 2005-02-08 | 2006-08-10 | Caveny William J | Low-density cement compositions, density-reducing additives, and methods of use |
| US7510609B2 (en) | 2005-02-08 | 2009-03-31 | Halliburton Energy Services Inc. | Low-density cement compositions, density-reducing additives, and methods of use |
| US7524369B2 (en) | 2005-02-08 | 2009-04-28 | Halliburton Energy Services, Inc. | Low-density cement compositions, density-reducing additives, and methods of use |
| US20060174804A1 (en) * | 2005-02-08 | 2006-08-10 | Caveny William J | Low-density cement compositions, density-reducing additives, and methods of use |
| US20070111901A1 (en) * | 2005-11-11 | 2007-05-17 | Reddy B R | Method of servicing a wellbore with a sealant composition comprising solid latex |
| US20070111900A1 (en) * | 2005-11-11 | 2007-05-17 | Reddy B R | Sealant compositions comprising solid latex |
| US8940670B2 (en) | 2007-05-10 | 2015-01-27 | Halliburton Energy Services, Inc. | Cement compositions comprising sub-micron alumina and associated methods |
| US9199879B2 (en) | 2007-05-10 | 2015-12-01 | Halliburton Energy Serives, Inc. | Well treatment compositions and methods utilizing nano-particles |
| US8476203B2 (en) | 2007-05-10 | 2013-07-02 | Halliburton Energy Services, Inc. | Cement compositions comprising sub-micron alumina and associated methods |
| US8586512B2 (en) | 2007-05-10 | 2013-11-19 | Halliburton Energy Services, Inc. | Cement compositions and methods utilizing nano-clay |
| US8603952B2 (en) | 2007-05-10 | 2013-12-10 | Halliburton Energy Services, Inc. | Cement compositions and methods utilizing nano-clay |
| US8685903B2 (en) | 2007-05-10 | 2014-04-01 | Halliburton Energy Services, Inc. | Lost circulation compositions and associated methods |
| US8741818B2 (en) | 2007-05-10 | 2014-06-03 | Halliburton Energy Services, Inc. | Lost circulation compositions and associated methods |
| US9765252B2 (en) | 2007-05-10 | 2017-09-19 | Halliburton Energy Services, Inc. | Sealant compositions and methods utilizing nano-particles |
| US9512352B2 (en) | 2007-05-10 | 2016-12-06 | Halliburton Energy Services, Inc. | Well treatment fluids and methods utilizing nano-particles |
| US9512351B2 (en) | 2007-05-10 | 2016-12-06 | Halliburton Energy Services, Inc. | Well treatment fluids and methods utilizing nano-particles |
| US9206344B2 (en) | 2007-05-10 | 2015-12-08 | Halliburton Energy Services, Inc. | Sealant compositions and methods utilizing nano-particles |
| US7708071B2 (en) | 2008-08-14 | 2010-05-04 | Halliburton Energy Services, Inc. | Cement compositions comprising aluminum chloride and associated methods |
| US20100038084A1 (en) * | 2008-08-14 | 2010-02-18 | Roddy Craig W | Cement Compositions Comprising Aluminum Chloride and Associated Methods |
| US8291989B2 (en) | 2009-12-18 | 2012-10-23 | Halliburton Energy Services, Inc. | Retrieval method for opposed slip type packers |
| US20110147013A1 (en) * | 2009-12-18 | 2011-06-23 | Marion Dewey Kilgore | Retrieval Method For Opposed Slip Type Packers |
| US20140352963A1 (en) * | 2011-06-17 | 2014-12-04 | Amir H. Mahmoudkhani | Powder Defoaming Compositions and Methods of Reducing Gas Entrainment In Fluids |
| US20150246666A1 (en) * | 2014-02-28 | 2015-09-03 | Tramec Sloan, Llc | Modulator valve |
| US9387846B2 (en) * | 2014-02-28 | 2016-07-12 | Tramec Sloan, Llc | Modulator valve |
Also Published As
| Publication number | Publication date |
|---|---|
| NO922429L (en) | 1992-12-22 |
| CA2071722C (en) | 2000-11-21 |
| DE69214360D1 (en) | 1996-11-14 |
| CA2071722A1 (en) | 1992-12-22 |
| EP0519756B1 (en) | 1996-10-09 |
| DE69214360T2 (en) | 1997-02-20 |
| NO922429D0 (en) | 1992-06-19 |
| EP0519756A1 (en) | 1992-12-23 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US5151203A (en) | Composition and method for cementing a well | |
| US5049288A (en) | Set retarded cement compositions and methods for well cementing | |
| US5571318A (en) | Well cementing methods and compositions for use in cold environments | |
| US4941536A (en) | Set retarded cement compositions and methods for well cementing | |
| US5398759A (en) | Set retarded ultra fine cement compositions and methods | |
| US5135577A (en) | Composition and method for inhibiting thermal thinning of cement | |
| US6270565B1 (en) | Methods and compositions for cementing pipe in well bores | |
| US5588488A (en) | Cementing multi-lateral wells | |
| US4258790A (en) | Well cementing method using low fluid-loss cement slurry | |
| US3132693A (en) | Composition comprising hydroxyethyl cellulose, polyvinylpyrrolidone and organic sulfonate, cement slurry prepared therefrom and method of cementing wells therewith | |
| US3071481A (en) | Cement composition | |
| US3662830A (en) | Aqueous hydraulic cement composition having improved retardation to set and use thereof in high temperature environments | |
| US5340860A (en) | Low fluid loss cement compositions, fluid loss reducing additives and methods | |
| US4632186A (en) | Well cementing method using an AM/AMPS fluid loss additive blend | |
| US7048054B2 (en) | Cement compositions containing coarse barite, process for making same and methods of cementing in a subterranean formation | |
| US7111684B2 (en) | Subterranean fluids having improved environmental characteristics and methods of using these fluids in subterranean formations | |
| EP1051368A1 (en) | Universal well cement additives and methods | |
| EP1213270A1 (en) | Well cement fluid loss control additive | |
| US3937282A (en) | Method for cementing wells in low temperature formations | |
| US5341881A (en) | Cement set retarding additives, compositions and methods | |
| US7357834B2 (en) | Cement composition for use with a formate-based drilling fluid comprising an alkaline buffering agent | |
| EP1336594A1 (en) | Cement compositions for sealing subterranean zones | |
| US3754953A (en) | Aqueous hydraulic cement composition having improved r etardation to set and use thereof in high temperature environments | |
| US4124075A (en) | Use of oil-wetting spacers in cementing against evaporites | |
| US3753748A (en) | Hydraulic cement retarder composition |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| AS | Assignment |
Owner name: HALLIBURTON COMPANY, A CORPORATION OF DE, OKLAHOMA Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNORS:RILEY, WENDELL D.;CHILDS, JERRY D.;REEL/FRAME:005763/0383 Effective date: 19910708 |
|
| STCF | Information on status: patent grant |
Free format text: PATENTED CASE |
|
| FEPP | Fee payment procedure |
Free format text: PAYOR NUMBER ASSIGNED (ORIGINAL EVENT CODE: ASPN); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY |
|
| FPAY | Fee payment |
Year of fee payment: 4 |
|
| FPAY | Fee payment |
Year of fee payment: 8 |
|
| FPAY | Fee payment |
Year of fee payment: 12 |